EP0293191B1 - Fluide de forage et de complétion - Google Patents

Fluide de forage et de complétion Download PDF

Info

Publication number
EP0293191B1
EP0293191B1 EP88304749A EP88304749A EP0293191B1 EP 0293191 B1 EP0293191 B1 EP 0293191B1 EP 88304749 A EP88304749 A EP 88304749A EP 88304749 A EP88304749 A EP 88304749A EP 0293191 B1 EP0293191 B1 EP 0293191B1
Authority
EP
European Patent Office
Prior art keywords
mud
glycerine
drilling
glycol
water
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Expired - Lifetime
Application number
EP88304749A
Other languages
German (de)
English (en)
Other versions
EP0293191A3 (en
EP0293191A2 (fr
Inventor
Thomas E. Peterson
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Hydra Fluids Inc
Original Assignee
Hydra Fluids Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Hydra Fluids Inc filed Critical Hydra Fluids Inc
Publication of EP0293191A2 publication Critical patent/EP0293191A2/fr
Publication of EP0293191A3 publication Critical patent/EP0293191A3/en
Application granted granted Critical
Publication of EP0293191B1 publication Critical patent/EP0293191B1/fr
Anticipated expiration legal-status Critical
Expired - Lifetime legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/04—Aqueous well-drilling compositions
    • C09K8/14—Clay-containing compositions
    • C09K8/18—Clay-containing compositions characterised by the organic compounds
    • C09K8/22—Synthetic organic compounds
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
    • Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y10S507/00—Earth boring, well treating, and oil field chemistry
    • Y10S507/925—Completion or workover fluid

Definitions

  • This invention relates to fluids for use when drilling and completing boreholes, and a method of preparing the same.
  • Drilling mud or drilling fluid is a more-or-less complex mixture of chemicals used in drilling of a well to perform a variety of functions.
  • Drilling mud comprises a liquid or slurry that is pumped down the drill string to exit through nozzles in the bit immediately adjacent the formation being penetrated.
  • the drilling mud flows upwardly in the annulus between the drill string and the wall of the hole to the surface and provides a variety of functions.
  • the drilling mud cools and lubricates the bit, delivers hydraulic horsepower to the bit, carries cuttings upwardly in the hole during circulation, suspends the cuttings in the bore hole when circulation stops, prevents blowouts, minimizes water loss into permeable formations, lubricates between the drill string and the bore hole wall and performs assorted other functions.
  • drilling muds There are all sorts of drilling muds. The most elementary drilling mud is water mixed with drilled solids and is often called "native" drilling mud. Some of the drilled solids are clays which, when finely ground, provide several of the functions of drilling mud. Some of the drilled solids add weight to the slurry which raises the density of the mud to 1.1-1.18 Kg/l (9.2 -9.9 lbs/U.S. gallon) which is sufficient to control normal pressures at shallow depths in many actively drilled areas.
  • Native mud was the earliest used in the rotary drilling of oil and gas wells. It was soon discovered that native drilling mud provides almost no control over the loss of water into permeable formations, tends to wash out or enlarge the diameter of the hole, accumulate shale balls on the bit and have other major disadvantages. Since that time, a wide variety of chemicals have been added to drilling mud to overcome real or perceived problems with native drilling mud.
  • One desirable characteristic of a drilling mud is that it sets up or gels, like Jello®, as it sits quietly. This characteristic is desirable so that cuttings or weight material in the drilling mud don't fall by gravity through the drilling mud toward the bottom of the hole when circulation stops. This characteristic is imparted to drilling mud by a gelling agent, such as drilled solids, bentonite and/or subbentonitic clays or mixtures thereof.
  • a drilling mud creates a filter cake of low permeability on the face of permeable formations.
  • the filter cake should be relatively thin and hard as opposed to thick and gooey.
  • the filter cake is created because the pressure in the borehole exceeds the pressure in a permeable formation penetrated thereby and liquid from the mud is moved into the permeable formation, leaving on the face of the formation a filter cake comprising the solids entrained in the mud.
  • the liquid lost to the formation is called filtrate.
  • filtrate When a large amount of filtrate passes across the formation face, a thick filter cake is deposited.
  • a small amount of filtrate passes across the formation face, a thin filter cake is deposited.
  • One function of the filter cake is to limit additional filtrate loss into the formation after the filter cake is created.
  • a wide variety of chemicals have been used to produce thin filter cakes or reduce filtrate loss, such as carboxymethyl cellulose, lignite, lignosulfonates, *Resin-X®- available from *Magobar®, *Miltemp® - a high temperature polymer available from *Milpark®, *Claytemp® - a polymer available from *Barclays®, *Soltex® - an asphalt based material available from Drilling Specialty and the like. *Trade Mark.
  • One purpose of the good filter cake is to reduce the quantity of filtrate lost to a permeable formation which is desirable for two reasons.
  • a fresh water filtrate for example, causes many clays such as montmorillonite and ilite to swell.
  • Sodium hydroxide is added to many drilling muds to raise the pH thereof substantially because it was learned years ago that an alkaline drilling mud does not swell clays as contrasted to a neutral or acidic drilling mud.
  • most pre-existing muds to which the additives of this invention are used are quite alkaline because sodium hydroxide has usually been added thereto.
  • the use of sodium hydroxide is typically suspended because the glycerines used are sufficiently alkaline to keep the pH high.
  • a completion fluid is a liquid material used during the completion phase of a well, i.e. while perforating a productive formation or conducting operations on a well after it has been drilled and cased but excluding formation fracturing operations.
  • a completion fluid differs from a drilling fluid mainly because it does not have to carry large quantities of cuttings upwardly in the annulus of the well bore, the only cuttings produced during completion operations being relatively small quantities of cement, cast iron and rubber, as may occur when drilling up DV tools, bridge plugs, squeeze jobs or the like.
  • completion fluids do not normally contain a gelling agent unless the fluid is very heavy and weighted with a solid weighting agent.
  • There is not as much a requirement for lubrication in a completion fluid because there is considerably less friction between the inside of oilfield casing and a work string than between the bore hole wall and a drill string.
  • completion fluids must have properties similar to drilling muds, i.e. they must be non-damaging to potentially productive formations, they must be sufficiently heavy to offset the bottomhole pressure of permeable formations and the like.
  • the fluid of this invention is eminently suitable as a completion fluid because it does not swell clays which may be present in productive formations, it is capable of withstanding significantly high bottom hole temperatures without degradation, its flow characteristics are not degraded by the introduction of solid, liquid or gaseous contaminants, it can be weighted to any reasonable density for pressure control and it is rather inexpensive.
  • a completion fluid made in accordance with this invention is quite suitable for use behind a packer to provide a non-corrosive relatively heavy liquid.
  • the present invention seeks to provide an improved drilling mud which is stable at high temperatures, which has excellent lubricating qualities and which is particularly non-damaging to common clays found in permeable formations potentially productive of hydrocarbons.
  • This invention also seeks to provide an improved completion fluid which is particularly non-damaging to common clays found in permeable formations potentially productive of hydrocarbons.
  • the present invention provides a fluid for use when drilling and/or completing a borehole, comprising water, a defoamer, and 6 to 90 volume percent of a water soluble glycerine selected from the group consisting of polyglycerine and mixtures of polyglycerine with glycerine.
  • the defoamer may be a glycol selected from the group consisting of alkylene glycol, polyalkylene glycol, and mixtures thereof, and may be present in an amount in the range of 2 to 50 volume percent of the water soluble glycerine and glycol, and is typically present in an amount in the range of 2 to 50 volume percent of the water soluble glycerine.
  • the water soluble glycerine may provide at least 25 volume percent of the fluid.
  • the fluid may incorporate a gelling agent, which may be in particulate form, e.g. drilled solids, bentonite, subbentonitic clays, and mixtures thereof.
  • the fluid may incorporate lignite.
  • the fluid according to the invention may be circulated in a borehole through a heaving shale substratum while the borehole is being drilled and/or completed.
  • US-A-2 191 312 discloses a drilling fluid intended to prevent the disintegration of a heaving shale which is defined as one which, in contact with the ordinary drilling mud, swells or disintegrates spontaneously so much operation.
  • the drilling fluid comprises a suspension of clay in a mixture of water and at least 20% by weight of glycerol, and preferably more than 40% by volume of glycerol.
  • Cannon discloses only the use of glycerol, i.e. simple glycerine and in an amount of at least 20% by weight of the mud and preferably 40% or more.
  • the present invention excludes the use of glycerine alone, and requires the fluid to include a polyglycerine or a mixture of a polyglycerine with glycerine with a lower limit of 6 volume percent.
  • polyglycerine e.g. diglycerine, triglycerine and others are quite superior to simple glycerine in inhibiting shale hydration, dispersion or disintegration.
  • the polyglycerines in the fluid can be used at a much lesser concentration to achieve the same degree of shale disintegration obtained with glycerine alone, or to obtain a quite improved degree of inhibition of shale disintegration when used at the same concentration as the glycerol used in the drilling fluid disclosed by Cannon.
  • Enough base mud was made up to conduct all of the tests from one batch of mud. This reduces variation between batches of mud and their effect on interpretation of data.
  • the base mud was kept under refrigeration at 4°C to prevent hydrolysis of organic constituents and decomposition due to bacterial activity until ready for use.
  • Union Carbide LO 500 a well known anti-foam defoamer was used as needed. *Trade Mark.
  • the residue was sieved from the 10 mesh screen and put on a tared drying dish where the sample was taken to complete drying at 105° C, cooled and weighed. The residue was then calculated to provide a percent recovery value.
  • caustic soda was added at 20 g/l (7 lbs/bbl) after addition of the glycerine to the base mud. This concentration is equal to the caustic soda used on the previous tests at 30%(vol) of *U.S.P. glycerine and *Dow W-80.
  • Bentonite used in oil field mud is a fine powder and is added to ordinary drilling mud by simply pouring it out of a sack into a hopper emptying into a conduit through which mud is flowing.
  • the bentonite particles hydrate and swell by adsorption of water contained in the drilling mud.
  • Dry powdered bentonite added to a mud system of this invention is not water wet and accumulates in clay clumps floating on top of the mud.
  • the bentonite is accordingly not wet by the water in the drilling mud.
  • bentonite is prehydrated, i.e. it is mixed with water in a separate tank to form a slurry which is then introduced into the fluid of this invention.
  • Drilling the same materials with a mud of this invention has little or no perceivable affect on the drilling mud.
  • a simple experiment illustrates the peculiar result. 500 ml of a mixture is prepared in a beaker, the mixture containing 40% water and 60% by volume of a glycerine-glycol solution. A small quantity of salt less than enough to supersaturate the solution is poured into the beaker and the beaker shaken well. Within a minute or two, salt particles can be seen settling out in the bottom of the beaker. Little or no salt enters the solution even though the liquid phase is 40% water. Thus, salt cannot contaminate the solution and salt particles are merely suspended like a non-soluble material.
  • the filtrate does not swell clays such as montmorillonite, ilite or the like when the proportion of glycerines is sufficiently high.
  • the filtrate produced in a standard API filter press is a solution of water, glycerine and defoamer in the same proportions as in the drilling mud.
  • a montmorillonite tablet dropped into a beaker of the filtrate where the glycerine concentration is above 25-30% by volume shows no perceptible swelling of the tablet in two days.
  • a montmorillonite tablet added to fresh water swells and disintegrates in a minute or two.
  • swelling of a montmorillonite tablet is slowed significantly.
  • swelling of montmorillonite tablets is progressively reduced.
  • Drilling of a typical well begins by using a so called “spud” mud.
  • spud mud is prepared by pumping highly treated mud from a previous well into a vacuum truck and watering it down with sufficient water to make it thin.
  • spud mud is prepared by mixing bentonite in water so the resultant suspension contains 11-13 Kg (25-30lbs) of bentonite per barrel of water.
  • the surface shoe and cement are drilled, followed by drilling out under surface.
  • the additives of this invention are admixed with the pre-existing mud. It may be that there is sufficient gelling agent, i.e. drilled solids, bentonite, subbentonitic clays, and mixtures thereof, in the mud. In this event, a solution of glycerine and defoamer is simply added to the mud.
  • a slurry of bentonite and water may be prepared in a slug tank and slowly added to the mud tank or pit to increase the quantity of gel in the mud after adding glycerine and defoamer to the mud.
  • a slurry of bentonite and water may be prepared in a slug tank and slowly added to the mud tank or pit while contemporaneously adding a solution of glycerine and defoamer to the mud.
  • dry powdered bentonite cannot be added to a mud system containing adequate quantities of glycerine and defoamer because the bentonite is not wet by the liquid phase.
  • the volume of a mud system is the sum of the volume of the hole and the volume of the mud tanks or pits.
  • the volume of a mud tank or pit is usually assumed to be constant even though they partially fill up with drilled solids during the course of drilling a well.
  • the volume of the hole increases substantially with drilling because the hole gets deeper.
  • the volume of mud in a mud system has to increase during the course of drilling a well or the mud tank or pit will run dry. Accordingly, liquid is more-or-less continuously added to a mud system. In an ordinary water based drilling mud, liquid is added by allowing a stream of water from a water hose to flow into the mud return line or across the shale shaker.
  • water is added conventionally but the liquid additives are prepared and placed in a tank of adequate size, e.g. a frac tank, and periodically pumped into the mud tank.
  • a tank of adequate size e.g. a frac tank
  • the mud engineer clocks the time necessary to fill a five gallon bucket from the pump. If the analysis of the mud and the increase in hole volume will necessitate the daily addition of some volume of the glycerine-defoamer solution.
  • the mud engineer determines this needed volume addition and leaves instructions for each driller to operate the compressed air driven pump for a predetermined number of minutes each tour, thereby adding the necessary volume of glycerine-defoamer solution every eight hours or so.
  • a mud engineer conducts a variety of analyses on the drilling mud at frequent intervals, at least once a day. In the course of these tests, it is often determined that the sampled mud is deficient in one or more respects and appropriate corrective action is taken.
  • mud system of this invention there are usually only five things to do: (1) control the amount of gelling agent to be sure there is enough to carry drilled solids to the surface and provide sufficient gel strength to suspend solids if circulation is stopped; (2) control the filter loss of the mud by adding a filter loss reducer; (3) control the amount of glycerine-defoamer solution; (4) maintain the desired mud weight by adding weight material if necessary and (5) keep the amount of solids suspended in the system under control by using mud cleaning equipment such as a mud centrifuge, cyclone or the like.
  • mud cleaning equipment such as a mud centrifuge, cyclone or the like.
  • the desired amount of gelling agent in the mud varies substantially for a variety of reasons including the type gelling agent used.
  • High yield Wyoming bentonite which is a sodium montmorillonite, is the preferred gelling agent in modern drilling muds and is preferred with the mud of this invention.
  • Other types of clays are quite suitable, such as medium yield drilling clays, calcium montmorillonite clays, and drilled solids.
  • the amount of gelling agent to be used may range from 5% by weight of the mud up to as high as 75% by weight.
  • the amount of bentonite in a drilling mud is determined either by a measurement of the gel strength of the mud or by a test known in the art as an MBT test. If there is too much bentonite, liquid is added to the mud system until the bentonite is diluted to the desired concentration. If there is too little bentonite, bentonite is added in a slurry form as previously mentioned.
  • a filter loss reducer may be added to the mud.
  • the preferred filtrate loss reducer of this invention is powdered lignite, a conventional material for this purpose. Powdered lignite is added by mixing with water in a slug tank and then adding the slurry to the mud tank because the powdered lignite is not readily admixed with a drilling mud containing the glycerine-defoamer solution of this invention.
  • the glycerine component to be used in this invention is a polyglycerine selected from diglycerine, triglycerine, tetraglycerine, pentaglycerine and heavier polyglycerines as well as mixtures of glycerine (glycerol) and polyglycerine.
  • a preferred glycerine component is a mixture of glycerine and polyglycerines available from Dow Chemical Company, Freeport, Texas and is known as *Polyglycerine W-80.
  • This material is a hydroxyl functional liquid which consists of various glycerols in an aqueous solution having the following typical properties:
  • *Polyglycerine W-80 available from *Dow Chemical is a byproduct of some chemical manufacturing operation of which applicant is unaware. Thus, it would seem that the available material would vary from batch to batch, although no noticeable differences have been perceived in using this material in several wells. It is believed that *Polyglycerine W-80 is an azeotropic mixture of water and glycerines because heating this mixture causes the mixture to boil off at a constant temperature and creates a reduction in the volume of material but does not apparently change the composition of the remaining material. *Trade Mark.
  • the glycerine component in the drilling mud of this invention has a plurality of functions. It acts to lubricate the contacting surfaces between the drill pipe and the bore hole wall, to reduce filtrate in standard API mud filtrate tests with a filter press, to control the flow properties of the mud by lowering the yield point of the drilling mud and the plastic viscosity and to minimize sloughing shale problems.
  • a major function of the glycerine component is to get the water in the mud in solution and affect it in such a manner that drilled contaminates like salt, gypsum, anhydrite and calcium carbonate are held in suspension rather than in solution thereby preventing deterioration of the mud.
  • the exact mechanism is not yet understood, but it is clear that the mud of this invention does not wet ordinary drilled solids and thus does not swell clays of the type typically encountered in drilling a well.
  • a drilling mud of this invention includes at least 6% by volume glycerine component.
  • the proportion of glycerine component increases to 25-30% by volume, the rate of hydration of montmorillonite tablets decreases until substantially no swelling is perceptible. It is accordingly preferred that the proportion of glycerine component exceed 25%.
  • glycerine component Another reason why high concentrations of glycerine component are desirable relate to temperature stability.
  • Water based muds are not particularly suited for extremely high temperature holes, e.g. above 325° because the mud gets hot and a great deal of water boils off the mud after it returns to the surface and the pressure thereof is reduced.
  • a glycerine-water solution as the liquid phase of the drilling mud, the boiling point of the solution is raised substantially to a level significantly above that of water or glycerine alone.
  • the maximum desirable proportion of glycerine component is probably limited by temperature stability and is about 90% by volume.
  • a defoamer of any suitable type is used in an amount effective to eliminate foaming or reduce it to unobjectionable levels.
  • the preferred defoamer used in the drilling mud of this invention is a glycol selected from the group consisting of an alkylene glycol such as ethylene glycol, propylene glycol, and the like, a polyalkylene glycol such as polyethylene glycol, polypropylene glycol and mixtures thereof. It appears that polypropylene glycol is the preferred glycol because it is less sensitive to high temperatures found in many moderate to deep wells. In most wells of moderate temperature, it appears that any glycol will act satisfactorily.
  • defoamers are also usable in the fluid system of this invention such as *LD-8 - an alcohol based defoamer available from *Milpark, aluminium stearate and diesel, methyl ethyl ketone, methanol, *Barclay's defoamer, *CamServ defoamer, *Unibar defoamer and *Bosco defoamer. *Trade Mark. *Trade Mark
  • glycol is a preferred defoamer because it has a variety of other desirable attributes. It not only acts as a foam breaker or reducer to keep the glycerine from foaming excessively but also assists in controlling the flow properties of the fluid and reduces API filtrate loss.
  • glycol is used to eliminate foaming or reduce it to an unobjectionable level.
  • a greater quantity of glycol may be used to take advantage of some of its other advantageous properties if such are wanted.
  • the amount of glycol is proportional to the amount of glycerine component and varies between 2-50% by volume of the glycerine component.
  • the glycerine component is *Polyglycerine W-80 from Dow Chemical.
  • the amount of glycerine in the drilling mud is about .10 x .90 x .75 or about 6.6% by volume.
  • the mud properties at 12,078 feet were: weight - 11.5 #/gal funnel viscosity - 46 seconds plastic viscosity - 15 cP yield point - 9 cP gel strength - 2/6 API filtrate - 5.6 cc cake thickness 1.58 mm (2/32 inches) solids content - 23% chlorides - 19,000 ppm pH - 10.5
  • Drilling and logging progressed normally without difficulty.
  • a well in LaFource Parish Louisiana is drilled to 8000 feet using a conventional fresh water-caustic-bentonite-lignite-chrome lignosulfonate mud.
  • the well is sidetracked and 140 barrels of glycerine-glycol solution is added to the mud system, having a total volume of 1190 barrels.
  • the amount of glycol in the additive is 10%.
  • the glycerine component is *Polyglycerine W-80 from Dow Chemical.
  • the amount of glycerine in the drilling mud is about 145/1190 x 9 x .75 or about 8.2% by volume.
  • the mud properties at 2513 m (8246 feet) were: *Trade Mark.
  • glycerine-glycol solution Twenty to thirty barrels of glycerine-glycol solution is added daily to the mud system to maintain the glycerine concentration. In addition, bentonite and lignite are added daily. Periodically, barite is added for weight. At 10,330 feet hole angle is 43 °. Except for rig breakdowns, drilling proceeds normally to total depth. During one rig breakdown, the drill string is in the open hole and not moved for two hours. After the breakdown is corrected, the driller raises the travelling block and, after pulling 6795 kg (15,000 pounds) in excess of the weight of the drill string, the drill string comes loose. It was considered a minor miracle that the drill string wasn't stuck and attributed to the lubricity of the drilling mud of this invention.
  • a spud mud is prepared with fresh water by mixing 30# of bentonite per barrel of mud. To this mixture is added a quantity of glycerine mixture sufficient to amount to about 20% by volume of the mud system.
  • the glycerine mixture consists of 50% simple glycerol and 50% diglycerine along with enough Barclay's defoamer to prevent foaming.
  • a montmorillonite table is added to filtrate collected from an API filter press. No swelling of the tablet is noted.
  • a drilling mud is prepared by adding to a native mud-bentonite-caustic drilling mud enough liquid glycerine-glycol additive to constitute 55% by volume glycerine-glycol.
  • the glycerine is a mixture of 1/3 glycerine, 1/3 diglycerine and 1/3 triglycerine.
  • the glycol is 10% of the glycerine-glycol additive.
  • a montmorillonite tablet is added to filtrate collected from an API filter press. No swelling of the tablet is noted.
  • a drilling mud is prepared by adding to a native mud-bentonite-caustic-lignite-chrome lignosulfonate slurry enough liquid glycerine-defoamer additive to constitute 35% by volume of the mud.
  • the defoamer is Barclay's defoamer and constitutes 5% by volume of the additive.
  • a montmorillonite tablet is added to filtrate collected from an API filter press. No perceptible swelling of the tablet is noted.
  • a 15 #/gal completion fluid is desired.
  • Polyglycerine W-80 ⁇ , weighing 10 ⁇ .7 #/gal, is diluted with enough water to produce a 10 ⁇ #/gal mixture.
  • 5% by volume methanol is added to control foaming.
  • a bentonite-water slurry is added to provide 10 ⁇ # of bentonite per barrel of completion fluid.
  • a 9.5 #/gal completion fluid is desired.
  • a 50 ⁇ -50 ⁇ mixture of simple glycerine and diglycerine is diluted with enough water to weight 9.5 #/gal.
  • Barclay's defoamer in an amount of about 3% by volume. No barite or bentonite is used.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Dispersion Chemistry (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Bulkheads Adapted To Foundation Construction (AREA)
  • Lubricants (AREA)

Claims (10)

  1. Fluide pour une utilisation dans un forage et/ou une complétion d'un trou de forage, comprenant de l'eau, un agent anti-mousse et 6 à 90 pourcent en volume d'une glycérine hydrosoluble choisie dans le groupe formé par la polyglycérine et des mélanges de polyglycérine avec de la glycérine.
  2. Fluide selon la revendication 1, dans lequel l'agent anti-mousse est un glycol choisi dans le groupe formé par un alkylèneglycol, un polyalkylèneglycol et leurs mélanges.
  3. Fluide selon la revendication 2, dans lequel l'agent anti-mousse est un glycol choisi dans le groupe formé par l'éthylèneglycol, le propylèneglycol, le polyéthylèneglycol, le polypropylèneglycol et leurs mélanges.
  4. Fluide selon la revendication 2 ou la revendication 3, dans lequel le glycol est dans la gamme de 2 à 50 pourcent en volume de la glycérine hydrosoluble.
  5. Fluide selon l'une quelconque des revendications précédentes, dans lequel la glycérine hydrosoluble constitue au moins 25 pourcent en volume du fluide.
  6. Fluide selon l'une quelconque des revendications précédentes incorporant un agent de gélification.
  7. Fluide selon la revendication 6, dans lequel l'agent de gélification est sous forme particulaire.
  8. Fluide selon la revendication 7, dans lequel l'agent de gélification est choisi dans le groupe formé par les solides de forage, les argiles bentonite, sous-bentonite et leurs mélanges.
  9. Fluide selon l'une quelconque des revendications précédentes et incorporant de la lignite.
  10. Procédé de forage et/ou de complétion d'un trou de forage à travers un substratum de schiste gonflant dans lequel on fait circuler un fluide selon l'une quelconque des revendications précédentes dans le trou de forage.
EP88304749A 1987-05-26 1988-05-25 Fluide de forage et de complétion Expired - Lifetime EP0293191B1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US07/053,472 US4780220A (en) 1987-05-26 1987-05-26 Drilling and completion fluid
US53472 1987-05-26

Publications (3)

Publication Number Publication Date
EP0293191A2 EP0293191A2 (fr) 1988-11-30
EP0293191A3 EP0293191A3 (en) 1990-01-24
EP0293191B1 true EP0293191B1 (fr) 1994-12-28

Family

ID=21984491

Family Applications (1)

Application Number Title Priority Date Filing Date
EP88304749A Expired - Lifetime EP0293191B1 (fr) 1987-05-26 1988-05-25 Fluide de forage et de complétion

Country Status (5)

Country Link
US (1) US4780220A (fr)
EP (1) EP0293191B1 (fr)
CA (1) CA1296514C (fr)
DE (1) DE3852572D1 (fr)
MX (1) MX170158B (fr)

Families Citing this family (51)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4941981A (en) * 1987-12-04 1990-07-17 Baker Hughes Incorporated Modified non-polluting liquid phase shale swelling inhibition drilling fluid
US4963273A (en) * 1987-12-04 1990-10-16 Baker Hughes Incorporated Modified non-polluting liquid phase shale swelling inhibition drilling fluid and method of using same
US5248664A (en) * 1988-03-14 1993-09-28 Shell Oil Company Water base drilling fluids comprising oil-in-alcohol emulsion
US5083622A (en) * 1988-03-14 1992-01-28 Shell Oil Company Method for drilling wells
NO177012C (no) * 1988-03-14 1995-07-05 Shell Int Research Vannbasert borefluid
US5085282A (en) * 1988-03-14 1992-02-04 Shell Oil Company Method for drilling a well with emulsion drilling fluids
NO177011C (no) * 1988-03-14 1995-07-05 Shell Int Research Vannbasert borefluid
US5248665A (en) * 1988-03-14 1993-09-28 Shell Oil Company Drilling fluids comprising polycyclic polyether polyol
EP0339762A3 (fr) * 1988-04-25 1992-01-02 Baroid Technology, Inc. Composition anti-mousse pour fluides de forage à base d'eau
US5198416A (en) * 1988-09-30 1993-03-30 Shell Oil Company Alcohol-in-oil drilling fluid system comprising polycyclic polyetherpolyol
US5072794A (en) * 1988-09-30 1991-12-17 Shell Oil Company Alcohol-in-oil drilling fluid system
AU4687389A (en) * 1988-12-16 1990-06-21 Baker Hughes Incorporated Method of providing a stable suspension of non-swelling particulate matter
US5260269A (en) * 1989-10-12 1993-11-09 Shell Oil Company Method of drilling with shale stabilizing mud system comprising polycyclicpolyetherpolyol
US5673753A (en) * 1989-12-27 1997-10-07 Shell Oil Company Solidification of water based muds
US5515921A (en) * 1989-12-27 1996-05-14 Shell Oil Company Water-base mud conversion for high tempratice cementing
US5464060A (en) * 1989-12-27 1995-11-07 Shell Oil Company Universal fluids for drilling and cementing wells
US5423379A (en) * 1989-12-27 1995-06-13 Shell Oil Company Solidification of water based muds
US5076373A (en) * 1990-03-30 1991-12-31 Shell Oil Company Drilling fluids
US5198415A (en) * 1991-01-15 1993-03-30 Exxon Production Research Company Nontoxic, nonchloride, water-base, inhibitive fluid to stabilize water sensitive shale
DE4224537A1 (de) * 1992-07-27 1994-02-03 Henkel Kgaa Mineralische Additive zur Einstellung und/oder Regelung der Rheologie und Gelstruktur wässriger Flüssigphasen und ihre Verwendung
US5552377A (en) * 1993-04-20 1996-09-03 Kindred; Jack E. Mud sweep and spacer composition
US5361841A (en) * 1993-05-27 1994-11-08 Shell Oil Company Drilling and cementing with blast furnace slag/polyalcohol fluid
US5361842A (en) * 1993-05-27 1994-11-08 Shell Oil Company Drilling and cementing with blast furnace slag/silicate fluid
US5358044A (en) * 1993-05-27 1994-10-25 Shell Oil Company Drilling and cementing with blast furnace slag/soluble/insoluble alcohol
US5337824A (en) * 1993-06-28 1994-08-16 Shell Oil Company Coal slag universal fluid
US5439056A (en) * 1993-06-28 1995-08-08 Shell Oil Company Coal slag solidification of drilling fluid
US5363918A (en) * 1993-08-04 1994-11-15 Shell Oil Company Wellbore sealing with unsaturated monomer system
US5686396A (en) * 1994-12-23 1997-11-11 Shell Oil Company Efficiency of polyglycerol with other additives to remove water from shale
US6080704A (en) * 1997-03-11 2000-06-27 Halliday; William S. Glycols as gas hydrate inhibitors in drilling, drill-in, and completion fluids
US6297202B1 (en) 1999-01-04 2001-10-02 Halliburton Energy Services, Inc. Defoaming compositions and methods
US6635604B1 (en) 1999-02-11 2003-10-21 Baker Hughes Incorporated Low molecular weight water soluble organic compounds as crystallization point suppressants in brines
US6518223B2 (en) * 2000-08-14 2003-02-11 Grain Processing Corporation Drilling fluid, apparatus, and method
US6417142B1 (en) 2001-10-02 2002-07-09 Halliburton Energy Services, Inc. Defoaming methods and compositions
US6968898B2 (en) * 2002-06-28 2005-11-29 Halliburton Energy Services, Inc. System and method for removing particles from a well bore penetrating a possible producing formation
US7879767B2 (en) * 2004-06-03 2011-02-01 Baker Hughes Incorporated Additives for hydrate inhibition in fluids gelled with viscoelastic surfactants
US7150322B2 (en) * 2004-08-24 2006-12-19 Halliburton Energy Services, Inc. Cement compositions comprising environmentally compatible defoamers and methods of use
US7670423B2 (en) * 2005-06-03 2010-03-02 Halliburton Energy Services, Inc. Cement composition comprising environmentally compatible defoaming agents and methods of use
US7273103B2 (en) * 2005-06-03 2007-09-25 Halliburtoncenergy Services, Inc. Cement compositions comprising environmentally compatible defoaming agents and methods of use
US20080261836A1 (en) * 2007-04-20 2008-10-23 Filler Paul A Compositions for use in well servicing fluids
US20090131287A1 (en) * 2007-11-16 2009-05-21 Smith Kevin W Inhibiting hydration of shale using a polyol and potassium formate
US8071509B2 (en) 2007-11-27 2011-12-06 Engineered Drilling Solutions Inc. Glycerol based drilling fluids
CA2643251C (fr) * 2008-11-05 2014-06-03 Trican Well Service Ltd. Compositions de fluides d'hydrocarbures et leurs methodes d'utilisation
US20100125156A1 (en) * 2008-11-14 2010-05-20 Smith Kevin W Condensation reactions for polyols
DE102009050059B4 (de) * 2009-10-21 2018-01-04 Tracto-Technik Gmbh & Co. Kg Dosiervorrichtung, Mischanlage, Verfahren zum Einbringen eines pulverförmigen Mediums in eine Flüssigkeit sowie Verwendung einer Dosiervorrichtung
BRPI0905255A2 (pt) * 2009-12-28 2011-08-23 Petroleo Brasileiro Sa composição de fluido de completação para poços profundos e ultraprofundos em ambientes contendo co2
US9725641B2 (en) * 2012-03-29 2017-08-08 Axel R. Johnson Methods fluids by producing and employing oil and gas well drilling and completion fluids as well as hydraulic fracturing fluids employing triglyceride processing by products and propylene glycol recovered from aircraft deicing operations
US10676664B2 (en) 2012-03-29 2020-06-09 Axel R. Johnson Increased availability and reduced costs for viscoelastic surfactants used in hydrofracturing fluids
US10669468B2 (en) 2013-10-08 2020-06-02 Weatherford Technology Holdings, Llc Reusable high performance water based drilling fluids
CA2856942A1 (fr) 2014-07-16 2016-01-16 Trican Well Service Ltd. Boue aqueuse servant au transport de particules
GB2545579B (en) * 2014-12-23 2021-12-15 Halliburton Energy Services Inc Salt-free fluorous-invert emulsion fluid
CA2880646A1 (fr) 2015-01-30 2016-07-30 Trican Well Service Ltd. Composition et methode d'utilisation d'huiles naturelles polymerisables en vue du traitement d'agents de soutenement

Family Cites Families (16)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2109858A (en) * 1935-06-21 1938-03-01 Standard Oil Dev Co Drilling fluid for combating heaving shale
US2191312A (en) * 1937-09-18 1940-02-20 Standard Oil Dev Co Drilling fluid for combating heaving shale
US2575276A (en) * 1948-08-03 1951-11-13 Nat Aluminate Corp Process of minimizing foam production in steam generation
US2589949A (en) * 1949-12-15 1952-03-18 Standard Oil Dev Co Controlling drilling fluid viscosity
US2637692A (en) * 1950-10-27 1953-05-05 Union Oil Co Oil-base drilling fluids
US3236769A (en) * 1956-09-10 1966-02-22 Socony Mobil Oil Co Inc Drilling fluid treatment
US3407878A (en) * 1966-09-02 1968-10-29 Phillips Petroleum Co Lost circulation control
US3639233A (en) * 1969-03-18 1972-02-01 Dresser Ind Well drilling
US3633689A (en) * 1970-05-27 1972-01-11 Exxon Production Research Co Method for drilling wells
US3728259A (en) * 1970-05-27 1973-04-17 Exxon Production Research Co Composition for drilling wells and method for preparing same
US3953337A (en) * 1973-11-16 1976-04-27 Texaco Inc. Method of drilling wells employing water base drilling fluids
US4033893A (en) * 1975-11-20 1977-07-05 Nl Industries, Inc. Potassium-lime aqueous drilling fluids and method of preparing same
US4172800A (en) * 1976-06-21 1979-10-30 Texaco Inc. Drilling fluids containing an admixture of polyethoxylated, sulfurized fatty acids and polyalkylene glycols
US4425241A (en) * 1981-02-18 1984-01-10 Phillips Petroleum Company Drilling fluids
US4464269A (en) * 1981-07-29 1984-08-07 Exxon Research & Engineering Co. Additive composition for release of stuck drill pipe
US4561985A (en) * 1982-06-28 1985-12-31 Union Carbide Corporation Hec-bentonite compatible blends

Also Published As

Publication number Publication date
EP0293191A3 (en) 1990-01-24
US4780220A (en) 1988-10-25
CA1296514C (fr) 1992-03-03
EP0293191A2 (fr) 1988-11-30
MX170158B (es) 1993-08-10
DE3852572D1 (de) 1995-02-09

Similar Documents

Publication Publication Date Title
EP0293191B1 (fr) Fluide de forage et de complétion
US5120708A (en) Non-poluting anti-stick water-base drilling fluid modifier and method of use
US4561985A (en) Hec-bentonite compatible blends
AU2002365886B2 (en) Acid soluble, high fluid loss pill for lost circulation
EP0814232B1 (fr) Fluides de séparation pour la complétion de puits
EP0960259B1 (fr) Fluide de forage et d'entretien d'un puits contenant des aphrons
US5851958A (en) Olefins and lubricants, rate of penetration enhancers, and spotting fluid additives for water-based drilling fluids
CA2564566C (fr) Systeme de fluide de forage aqueux inhibiteur et procede de forage de sables et d'autres formations sensibles a l'eau
EP0495579B1 (fr) Fluide de forage
EP2132279B1 (fr) Boue de forage et procédé pour forer dans des formations contenant du charbon
US7825072B2 (en) Inhibitive water-based drilling fluid system and method for drilling sands and other water-sensitive formations
CA1121145A (fr) Fluide de forage contenant un derive de polysaccharide a reticulation croisee
US3989630A (en) Low solids shale controlling drilling fluid
US3654164A (en) Drilling fluids
Mondshine A new potassium based mud system
US5008025A (en) Sulfonate-containing polymer/polyanionic cellulose combination for high temperature/high pressure filtration control in water base drilling fluids
CA1261132A (fr) Xanthane a forte teneur en pyruvate, additif pour fluides de forage
WO2000043465A1 (fr) Fluide de forage en eaux profondes a base d'eau
US3146199A (en) Water base drilling fluid and method of drilling a well utilizing the same
WO1999009109A1 (fr) Additifs stabilisateurs de schiste argileux
EP0699729A1 (fr) Emulsions inverses sans hydrocarbures, dont la phase externe contient du poly(1,4-oxybutylene) glycol, pour utilisation dans les opérations de forage
NO176721B (no) Fluid for anvendelse i petroleumsbrönner, samt fremgangsmåte for å bore en brönn
Aung Drilling Fluid Systems and Practices in the Cooper and Eromanga Basins, Australia

Legal Events

Date Code Title Description
PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

AK Designated contracting states

Kind code of ref document: A2

Designated state(s): DE GB IT NL

PUAL Search report despatched

Free format text: ORIGINAL CODE: 0009013

AK Designated contracting states

Kind code of ref document: A3

Designated state(s): DE GB IT NL

17P Request for examination filed

Effective date: 19900716

17Q First examination report despatched

Effective date: 19911010

GRAA (expected) grant

Free format text: ORIGINAL CODE: 0009210

AK Designated contracting states

Kind code of ref document: B1

Designated state(s): DE GB IT NL

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: NL

Effective date: 19941228

Ref country code: IT

Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRE;WARNING: LAPSES OF ITALIAN PATENTS WITH EFFECTIVE DATE BEFORE 2007 MAY HAVE OCCURRED AT ANY TIME BEFORE 2007. THE CORRECT EFFECTIVE DATE MAY BE DIFFERENT FROM THE ONE RECORDED.SCRIBED TIME-LIMIT

Effective date: 19941228

REF Corresponds to:

Ref document number: 3852572

Country of ref document: DE

Date of ref document: 19950209

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: DE

Effective date: 19950329

NLV1 Nl: lapsed or annulled due to failure to fulfill the requirements of art. 29p and 29m of the patents act
PLBE No opposition filed within time limit

Free format text: ORIGINAL CODE: 0009261

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT

26N No opposition filed
REG Reference to a national code

Ref country code: GB

Ref legal event code: 732E

REG Reference to a national code

Ref country code: GB

Ref legal event code: IF02

PGFP Annual fee paid to national office [announced via postgrant information from national office to epo]

Ref country code: GB

Payment date: 20040615

Year of fee payment: 17

PG25 Lapsed in a contracting state [announced via postgrant information from national office to epo]

Ref country code: GB

Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES

Effective date: 20050525

GBPC Gb: european patent ceased through non-payment of renewal fee

Effective date: 20050525